Espírito Santo
3D Petroleum System Modeling and Exploration Risk Assessment of the Plays, Leads and Prospects of the Rift and Drift Sections of the Shallow Water Gas Province in the Central Espírito Santo Basin
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This report is a well documented study focusing mainly on the gas producing area in the northern Espírito Santo Basin. It aims to evaluate the petroleum plays based on the geological, seismic and geochemical concepts available at the time of the study. A careful seismic interpretation and leads identification were performed on 924 km² of 3D data and 25 2D seismic lines comprising 1,056 km. Additionally, 10 crude oils and 14 wells and hundreds of rock data were used to ascertain source rocks (pyrolysis, TOC), depositional facies and hydrocarbon thermal maturity of oils and source rocks (biomarkers, diamondoids and isotopes) for the correlation and thermal control of source rocks maturity with %Ro data (Vitrinite Reflectance).
The geological and seismic interpretation work produced a complete geological framework that was used to perform a 3D basin modeling evaluation and exploration risk assessment of the identified leads in the study area. The modeling results include the distribution and oil types (oil-condensates-gas) with quantitative evaluation of liquid accumulations, drainage areas and migration pathways. This study also provides an evaluation of biodegradation, as it is a main risk in the shallow water areas.
The integration of the HRGT results of oils, condensates and gases suggests the presence of three well recognized petroleum systems in this basin, one sourced from two intervals of the rift sequence of the Cricaré formation, the Albian-Cenomanian/Turonian marine calcareous mudstone sequence and the Tertiary deltaic rocks in the vicinity of the Rio Doce River Delta. The compositional modeling results provide a sound basis to interpret which accumulation is likely to be an oil or gas prone prospect.
Full references of all images are listed in the reports
- Executive Summary
- Source rocks
- Maturity
- Migration
- Pre-Salt Reservoirs
- Introduction
- Regional Geology
- Regional Characterization of the Fluid Systems
- Regional Characterization of the Source Rock Systems
- Identification and Distribution of the Petroleum Systems
- Geological Framework and Seismic Analysis
- Data and Geologic Framework
- Methodology
- Geologic Framework
- Isopach Map Analysis
- Seismic Attribute Analysis
- Lead and Geological Risk Analysis
- Basin Modeling
- Model Input
- Salt Restoration Through Time
- Calibration
- Source Rock Definition
- Boundary Conditions
- Paleo Water Depth
- Surface Water Interface
- Basal Heat Flow Maps
- Maturity Results Of The Source Rocks
- Maturity, Transformation Rates and Expulsion Time
- Maturation of the Barremian Source Rock
- Transformation Ratio of the Barremian source rock
- Expulsion time for the Barremian source rock
- Maturation of the Aptian Source Rock
- Transformation Ratio of the Aptian source rock
- Expulsion time for the Aptian source rock
- Maturation of the Cenomanian Source Rock
- Transformation Ratio of the Cenomanian source rock
- Expulsion time for the Cenomanian source rock
- Maturation of the Paleocene-Eocene Source Rock
- Transformation Ratio of the Paleocene-Eocene Source Rock
- Expulsion time for the Paleocene-Eocene source rock
- Present Day Temperature of the Source Rocks
- Barremian source rock
- Aptian source rock
- Cenomanian source rock
- Paleocene-Eocene Source Rock
- Excess Hydraulic Pressure
- Petroleum Migration
- Accumulation Results
- Accumulations in the Lower_Rift_142_127Ma
- Accumulations in the Mid Rift
- Accumulations in the Aptian_120_113Ma
- Accumulations in the Albian-Cenomanian
- Accumulations in the UpK_Res_88_70Ma
- Accumulations in the UpK_70_68Ma
- Accumulations in the Up_Eocene_Res_45_38Ma
- Accumulations in the Olig_Res_28_27Ma
- Accumulations in the Olig_Mic_27_22Ma and Olig_Mic_22_18Ma Layers
- Mass Balance
- Conclusions
- Maturation
- Accumulations
- Appendix I
- Facies Maps
- Salt Restoration
- Maturity of source rocks
- Barremian source rock
- Aptian source rock
- References
- Location map of Blocks ESM384, ESM385, ESM386, ESM387 and ESM412 and ESM439 in Sector SES-AR2 of the Espírito Santo Basin. The map shows a 924 Km2-seismic cube of CGG 3D data as well as 25 seismic 2D lines, comprising 1,056 Km of public 2D data.
- Map of the Espírito Santo Basin showing the boundary with the Campos Basin (e.g. Vitoria Arch) and the gas and condensate fields of Peroá and Cangoá in the Central area.
- Stratigraphic chart of the Espírito Santo Basin showing the main source rocks and reservoir sequences.
- Tectonic compartments and distribution of main play types in the Espírito Santo Basin (modified from Biassusi et al., 1990).
- Geological section along the Cação, Peroá, Cangoá and Fragata fields near the Rio Doce River delta (Mod. from Van der Ven et al., 1998). Note the presence of compressive structures in the area of the gas/ condensate fields. These featuresare related to the Abrolhos volcanism that reached paroxysm during the early Tertiary.
- Stratigraphic charts of the Santos, Campos and Espírito Santo basins showing a similar geologic history from the rift age up to the Coniacian/Campanian stages.
- Petroleum accumulations discovered so far in the deep offshore Espírito Santo Basin (ex. Cachalote, Jubarte, Baleia Anã, Baleia Franca, Baleia Azul Argonauta and the mixed oils from Golfinho).
- Geochemical characteristics (n-alkanes and m/z 191) of oils from distinct petroleum systems recovered in the Espírito Santo Basin.
- The m/z 191 Triterpanes characteristic of oils from distinct petroleum systems recovered in the Espírito Santo Basin.
- M/Z 217 steranes characteristic of oils from distinct petroleum systems recovered in the Espírito Santo Basin.
- Biomarker data classified the oils as mixed lacustrine saline/marine (e.g., ESS-77, ESS-74, ESS-53, ESS-41 and ESS 25, etc.), marine (e.g., Cação Field, ESS-99 and ESS-41, among others) and lacustrine (e.g. ESS-104B, ESS-100 and ESS-103, etc.).
- The259 C30 Triterpane doublet characteristic of lacustrine and marine oils.
- The presence of several aromatic compoundstaken from mass chromatograms m/z 231 and m/z 245 allowed us to differentiate the oils derived from lacustrine and marine source rocks and corroborate the oils classified as marine deltaic mixed with lacustrine saline (e.g., ESS-77, ESS-74, ESS-53, etc) and marine carbonate (e.g., Cação Field, ESS-41 and ESS-25, among others).
- Results of m/z 231 Triaromatic steranes allowing the distinction between lacustrine and marine oils.
- The m/z 245 chromatograms of lacustrine and marine oils in the Espírito Santo Basin.
- M/Z 191 triterpanes, m/z 217 steranes and m/z 259TPP polyprenoids of oils from the mixed lacustrine and marine petroleum systems recovered in the study area of the Espírito Santo Basin.
- M/Z 231 and m/z 245 Triaromatic steranes confirming the mixture of lacustrine and marine oils in the Peroá and Cangoá accumulations in the study area.
- M/Z 191 triterpanes, m/z 217 steranes and m/z 259TPP polyprenoids characteristic of oil types such as mixed lacustrine and Cretaceous marine carbonate petroleum systems recovered in the Espírito Santo Basin.
- M/Z 231 and m/z 245 Triaromatic steranes confirming the mixture of lacustrine and Cretaceous marine carbonate oils in the accumulations near the Peroá and Cangoá fields, in the study area.
- Distribution of oil families in the Espírito Santo Basin showing the overlapping of several petroleum systems in the study area.
- Using biomarker analyses alone onlyoil A can be detected, whereas using both diamondoid and biomarker analyses enable the identification of a mixture of two oils (oils A and B).
- Oil Thermal evolution behavior based on diamondoids and biomarker parameters.
- Extend of oil cracking of samples recovered in ES basin on diamondoids andbiomarker parameters.
- Compositional and isotopic gas data for the Espírito Santo Basin.
- Multivariate data of the gases in the Espírito Santo Basin.
- There are three main source rock intervals identified in the Espírito Santo Basin. The lacustrine source rocks display up to 10% TOC and thicknesses in the range 200 to 400 meters.
- Geochemical log of 1-ESS-34, in the offshore Espírito Santo Basin, showing the stratigraphic position of the lacustrine brackish to saline water, organic-rich sediments of the Mariricu-Cricaré/ Lagoa Feia Formations. Note the presence of an Upper source interval, representing theSag stage, richer in terms of hydrocarbon potential than the Lower interval. The lower source represents the Rift stage.
- Geochemical log of 1-ESS-95A,in the offshore Espírito Santo Basin, showing the stratigraphic position of the lacustrine brackish to saline water and the marine anoxic, organic-rich sediments of the Mariricu-Cricaré / Lagoa Feia, Regência and Urucutucaformations. Note the presence of two distinct anoxic intervals in the marine section.
- Geochemical log of 1-ESS-103A, in the offshore Espírito Santo Basin, showing the stratigraphic position of the lacustrine brackish to saline water and of the marine anoxic, organic-rich sediments of the Mariricu-Cricaré/ Lagoa Feia, Regência and Urucutuca formations. Note the presence of an anoxic event in the Urucutuca Formation.
- TOC (%) content vs thickness of the marine Tertiary organic-rich interval in the Espírito Santo Basin close to the studied blocks.
- Plot of the natural series for all the samples analyzed in the southern Espírito Santo Basin. As can be observed, the oil generation threshold begins at around 4,500 – 4,600m, with peak generation commencing between 4,800 and 5,000m.
- Distribution of the oil family systems in the Espírito Santo Basin.
- Stratigraphic chart showing the mapped horizons of the shallow-water Espírito Santo Basin.
- Middle Miocene Structural map (scale in meters).
- Oligocene Structural depth map (scale in meters)
- Upper Eocene depth Structural map (scale in meters).
- Upper Cretaceous Structural map (scale in meters).
- Albian depth Structural map (scale in meters).
- 3D view of the top of salt.
- 3D view of the base of salt.
- 3D view of thebasement.
- Isopach map of the Oligocene sequence (scale in meters).
- Isopach map of Upper Eocene sequence (scale in meters).
- Isopach map of Albian sequence (scale in meters).
- Seismic Attribute map of the Oligocene (Average Trough Amplitude).
- Seismic Attribute map of the Upper Eocene (Average Trough Amplitude).
- Seismic Attribute map of the Albian (Average Trough Amplitude).
- Seismic Line crossing the Peroá Field, observe the position of the 1ESS-0077-ES well.
- Seismic Line crossing the Peroá Field, observe the position of the 3ESS-0082-ES well.
- Seismic Line crossing the Peroá Field. Cross-section between wells 1-ESS-89, 3-ESS-82 and 1-ESS-77 and 1-ESS-0012-ES.
- Seismic Line and attribute map of the Cangoá Field.
- Seismic cross-section between wells 1-ESS-68, 1-ESS-67 and 1-ESS- 74.
- 2D Seismic line showing structural traps in block ES M384.
- Albian structural map shows a closed structure at a depth of 4,600 mdepth in the block ES M384 area.
- Upper Eocene depth structural map of block ES M384.
- 2D Seismic line with structural traps (leads) in the block ES M385.
- 3D Seismic line showing structural traps (leads) in block ES M385.In the structural depth map of the Oligocene (Figure 58), only stratigraphic traps can be expected. Oligocene opportunities could be sandstone from the Urucutuca Formation, as suggested by the seismic attribute map in Figure 59.
- Oligocene depth structural map of block ES M385.
- Oligocene Seismic Attribute map in the block ES M385.
- Upper Eocene depth structural map of block ES M385.
- Albian depth structural map of blockES M385.
- 2D Seismic line showing structural traps in blocks ES M386 and ES M439.
- Oligocene depth structural map of block ES M386.
- Upper Eocene structural map of block ES M386.
- Albian depth structural map of block ES M386.
- 2D seismic line with structural traps in block 387.
- Oligocene depth structural map of block ES M387.
- Upper Eocene depth structural map of block ES M387.
- Albian depth structural map of block ES M387.
- 3D Seismic line showing structural traps in block ES M412.
- 3D Seismic line showing structural traps in block ES M412.
- Oligocene depth structural map of block ES M412
- Upper Eocene depth structural map of block ES M412.
- Albian depth structural map of block ES M412.
- 2D Seismic line with trap structures of block ES M439.
- Oligocene structural map of block ES M439
- Upper Eocene structural map of block ES M439.
- Albian structural map of block ES M439.
- Cross-section of the geological model.
- Model sequences defined by nine depth interpreted seismic horizons, showing the 4 source rock levels and main reservoir intervals, including the assigned ages.
- Facies map of the Oligocene reservoirs (Olig_Re_28-27 Ma).
- Facies map of the Upper Eocene reservoirs (UP_Eoc_Res_45-38 Ma). Besides the well data, seismic attributes were used from Figure 46, particularly to separate the lithologies: 70sh30ss (dark green) from 60sh40ss (light green). The seismic attributes only exist in the area enclosed by the yellow rectangle.
- Facies map of the Upper Cenomanian (UpK_70-68_Ma).
- Facies map of the Upper Cenomanian reservoirs (UpK_88-70 Ma).
- Facies map of the Albo_Cenomanian reservoir (Albo_Cenomanian_Res_100-97_Ma).
- Facies map of the Aptian (120-113 Ma), Mid_Rift (126-123 Ma) and Lower-Rift (142-127 Ma) layers.
- Geometry of the salt layer at 111 Ma.
- Geometry of the salt layer at 100 Ma.
- Geometry of the salt layer at 90 Ma. Note that the salt layer is building up irregularly, with overhangs.
- Geometry of the salt layer at 70 Ma.
- Geometry of the salt layer at 60 Ma.
- Geometry of the salt layer at 50 Ma.
- Geometry of the salt layer at 45 Ma.
- Geometry of the salt layer at 38 Ma.
- Geometry of the salt layer at 30 Ma.
- Geometry of the salt layer at 28 Ma.
- Geometry of the salt layer at 27 Ma.
- Geometry of the salt layer at 22 Ma.
- Geometry of the salt layer at 21 Ma.
- Geometry of the salt layer at 18 Ma.
- Geometry of the salt layer at 13 Ma.
- Geometry of the salt layer at 8 Ma.
- 3D view of the salt layerat 60 Ma. Note that small windows in the salt layer opened already in the northern part of the study area.
- 3D view of the salt layer at 50 Ma.
- 3D view of the salt layer at 28 Ma.
- 3D view of the salt layer at present day. The salt dome in the south has a different pink value because its evolution was shaped by the salt piercing tool.
- Calibration plots for vitrinite (%Ro) and temperature (BHT) of a well near Cangoá Field.
- Calibration plots for vitrinite (%Ro) and temperature (BHT) of a well representative of the thermal state and maturation in the southwest corner of the model.
- Calibration plots for vitrinite (%Ro) and temperature (BHT) of a well close to Cangoá Field.
- Calibration plots for vitrinite (%Ro) and temperature (BHT) of a well near Peroá Field.
- Calibration plots for vitrinite (%Ro) and temperature (BHT) of a well near Peroá Field.
- Original organic carbon (%TOC) of the Upper Eocene source rock.
- Original organic carbon (%TOC) ofthe Paleocene-Eocene source rock.
- Primary cracking kinetics for the Talc-Stevensite source rock (IES_Alaskan_Tasmanite-BH056-4C).
- Primary cracking kinetics for the Coquinas source rock (IES_Boghead_Coal-BH005-4C).
- Primary cracking kinetics for the Albian source rock (IES_Toarcian_Shale-BH420-4C).
- Primary cracking kinetics for Paleocene-Eocene source rock (IES_Kimmeridge_Clay-BH263-4C).
- Waples (2000) reaction used to reproducethe secondary cracking from C2-C5 to methane. The histogram shows the activation energy versus initial ratio of transformation. The Arrhenius constant value of this reaction is 3.15e+28 m.y.-1.
- Pepper (1995), type I reaction used to simulate the secondary cracking from C6-C14 to C2-C5 and C15+ to C6-C14. The histogram shows the activation energy versus initial ratio of transformation. The Arrhenius constant value of this reaction is 3.15e+27 m.y.-1
- Pepper (1995), type II reaction used to simulate the secondary cracking from C6-C14 to C2-C5 and C15+ to C6-C14. The histogram shows the activation energy versus initial ratio of transformation. The Arrhenius constant value to this reaction is 3.15e+27 m.y.-
- Paleo water depth map at 30 Ma (in meters).
- Paleo temperature at the sea surface of the basin model. Based on Wygrala (1989).
- Map expressing high heat flow at 123 Ma (mW/m2). Note that the values are high but do not change much across the area (vary between 64 to 65 mW/m2).
- Heat flow map at present day (vary between 57 to 59 mW/m2).
- Generation windows of the Barremian source rock.Note that it is in the dry gas window all over the area. It is overmature in the yellow regions.
- Transformation ratio of the Barremian source rock (113 Ma).
- Expulsion peaks of the Barremian source rock, based on Transformation ratio of 20%. Generation rate presents values that can reach 190 mgHC/gC/My.
- Cross-section (white line) at the top of Barremian source rock along which transformation ratio values were extracted.
- Generation zonesof the Aptian source rock. Note that it is in the dry gas window over most of the area, except in the south where it is in wet gas window.
- Transformation ratio of the Aptian source rock at 95 Ma.
- Expulsion peaks of the Aptian source rock, based on transformation threshold of 20%. Generation rate values can reach 50 mgHC/gC/My. Note that there is minor generationfrom 87 to 70 Ma.
- Cross-section (white line) along whichtime plots were extracted.
- Map ofHydrocarbon zones for the Cenomanian source rock. Block 439 is in the Main Oil window, thus is favorable to contain accumulations with more liquid compounds relative to the other blocks.
- Transformation ratio map of the Cenomanian source rock at 30 Ma.
- Transformation ratio map of the Cenomanian source rock at present day.
- Expulsion peaks of the Cenomanian source rock, based on transformation ratio of 20%. Generation rate values can reach 25 mgHC/gC/My.
- Cross-section (white line) along which time plots of transformation ratio were extracted.
- Hydrocarbon windows of the Paleocene-Eocene source rock.
- Transformation ratio map of the Paleocene-Eocene source rock at present day.
- Expulsion peaks (lower panel) of the Eocene source rock, based on Transformation Ratio of 20%. Generation rate presents values that can reach 9 mgHC/gC/My.
- Location of the cross-section (white line) along which time plots of transformation ratio were extracted.
- Present day temperature of the Barremian source rock.
- Present day temperatures at the top of the Aptian source rock.
- Temperature of the Cenomanian source rock (present day).
- Temperature of the Paleocene -Eocene source rock (present day).
- Excess pressure map of the Aptian layer.
- Location of salt windows in the studied area (black areas inside the model). Note that there are windows in the salt layer in the vicinityof theCangoá and Peroá fields. A large gap in the salt layer window is located in block 385. Other windows are in blocks 386, 384 and 439.
- N-S geological section crossing the Peroá Field (“P” )in the model. Note the base of salt is not much tilted, which favors vertical migration in the area. Nevertheless, there were substantial losses of hydrocarbon to the borders.
- Southeast 3D view of the block showing variations in petroleum saturations. Petroleum reached the Peroá Field which originated from salt windows located in thenorth and northeast. Note also how the layers eastward of Peroá are extensively saturated.
- Southwest 3D view of the block showing a N-S section crossing the Cangoá Field. The colored cells are saturated with hydrocarbons. Petroleum originated from a salt window just at the NW border of the field and migrated vertically, breaking capillary pressure resistance, across the layered rocks near the salt dome walls.
- Southeast 3D view of the studied area (at present day). The main pathways of hydrocarbon from the pre-salt section to the post-salt section are controlled by the location of salt windows. The salt windows in this figure stand out by the colored areas saturated with hydrocarbons and by the arrows indicating their flow direction. The red arrows reveal that vapor hydrocarbons are actively migrating today.
- Southeast 3D view of the petroleum mass in layer Lower_Rift_142_127Ma at present day.
- Distribution of the petroleum mass in layer Lower_Rift_142_127Ma. See scale of the petroleum mass in the previous figure. The major composition of the accumulations is methane, whereas in the south (see B) of the studied area there are small percentages of heavier components in the vapor phase.
- Southeastern3D view of the petroleum mass distributed in the Mid_Rift layer. Note the high concentration of petroleum mass, located in the western half of the model: in the Cangoá and Peroá fields as well as in blocks ES M412 and ES M439.
- Composition and petroleum mass distribution in theMid_Rift layer. The major components of the accumulations are methane derived from the Coquinas and Talc-Stevensite source rocks.
- A Southeastern 3D view of the petroleum mass in the layer Aptian_120_113Malayer, located just below the salt layer.
- Shows a map of the petroleum mass (Mtons) in the layer Aptian_120_113Malayer (present day). As indicated by the colored circles, methane is the major component predicted for this layer.
- Distribution of the petroleum mass in the Albian-Cenomanian layer (present day).
- Southwestern3D view of the petroleum mass in the Albian-Cenomanian reservoir. In red we enhanced the accumulations with vapor dominated phase. The largest accumulation is located in the western part of the studied area, in Block 412.
- 3D view of the Petroleum mass distribution intheUpK_Res_88_70Ma layer at present day. Note that the simulation predicts an accumulation in block 385 and smaller ones in block 386 (they are structural-stratigraphic traps). There is relatively good convergence of petroleum to the northern border of block 439.
- Shows a map view of the petroleum mass distribution in theUpK_Res_88_70Ma layer (present day). Note the predicted accumulation in turbidites in block ES- M385.
- Petroleum mass distribution in the K_95_88Ma layer (present day). This is a very shaly interval; nevertheless, in some places the hydrocarbon column height can be large enough to break through upper layers.
- Shows a map of the petroleum mass distribution in the UpK_70_68Malayer (present day). The dashed yellow line outlines the best reservoir facies of this layer.
- Southwestern3D view of the petroleum mass distribution in the UpK_70_68Malayer at present day. Note that there is good convergence of petroleum in block ES M386 and ES M387. If good reservoir facies exist in these blocks, then there isgood probability to form economic accumulations.
- Shows a map of the mass distribution in layer Up_Eocene_Res_45_38Ma (present day). Note that we predict two substantial accumulations in block 439.
- Southwestern3D view of the petroleum mass distribution intheUp_Eocene_Res_45_38Malayer at present day.
- Southwestern3D view of petroleum mass in the Olig_Res_28_27Malayer at present day. Note we were able to reproduce the accumulation in the Peroá field. Accumulations are also predictedin Block ES M439.
- Southeastern3D view of petroleum mass in theOlig_Mioc_27_22Malayer at present day. The saturated cells indicate that hydrocarbons are leaking to the surface.
- Southwestern3D view of petroleum mass in theMioc_22_18Malayer at present day.
- The main layers in which substantial volumes of hydrocarbons have accumulated. Note the larger volumes associated with the Olig_Res_28_27Ma and Eoc_res_45_38Ma. Values are expressed in billion of barrels.
- Compositional contribution of each source rock (Talc-Stevensite, Coquinas, Albian and Cenomanian) to accumulations in the area.
- A Graph showing the cumulative volumes.The purple curve shows the total generated volumes; blue curve represents the total expelled and brown curve expresses total accumulation. All volumes are expressed in Bbbls.
- AGraph showing generated and expelled mass. The purple bars show generated volumes and blue bars represent the expelled volumes. All volumes are expressed in billions of barrels.
- Facies map of the Mioc_Plioc (8-0 Ma).
- Facies map of the Miocene (18-13 Ma).
- Facies map of the Miocene (22-18 Ma).
- Facies map of the Oligocene Miocene (27-22 Ma).
- Facies map of the Oligocene (28-27 Ma).
- Facies map of the Oligocene (30-28 Ma).
- Facies map of the Oligocene (38-30 Ma).
- Facies map of the Upper Eocene (45-38 Ma).
- Facies map of the Eocene (50-45 Ma).
- Facies map of the Pal_Eocene (60-50 Ma).
- Facies map of the UpK (70-68 Ma).
- Facies map of the UpK (88-70 Ma).
- Facies map of the K (95-88 Ma).
- Facies map of the Cenomanian (97-95Ma).
- Facies map of the Albo_Cenomanian reservoir (100-97 Ma).
- Facies map of the Albian (111-100Ma).
- Facies map of the Salt (113 Ma).
- Facies map of the Aptian (120-113 Ma).
- Facies map of the Aptian (123-120 Ma).
- Facies map of the Mid_Rift (126-123 Ma).
- Facies map of the Barremian_SR (127-126 Ma).
- Facies map of the Lower-Rift (142-127 Ma).
- Facies map of the Basement (150-142 Ma).
- 3D SaltEvolution (60 Ma).
- 3D SaltEvolution (50 Ma).
- 3D SaltEvolution (45 Ma).
- 3D SaltEvolution (38 Ma).
- 3D SaltEvolution (30 Ma).
- 3D SaltEvolution (28 Ma).
- 3D SaltEvolution (22 Ma).
- 3D SaltEvolution (18 Ma).
- 3D SaltEvolution (Present day).
- Transformation ratio of the Barremian source rock (113 Ma).
- Transformation ratio of the Barremian source rock (111 Ma).
- Transformation ratio of the Barremian source rock (100 Ma).
- Transformation ratio of the Barremian source rock(70 Ma).
- Transformation ratio of the Barremian source rock (present day).
- Transformation ratio of the Aptian source rock(95 Ma).
- Transformation ratio of the Aptian source rock(88 Ma).
- Transformation ratio of the Aptian source rock(Present day).
- Transformation ratio of Cenomanian source rock (30 Ma).
- Transformation ratio of the Cenomanian source rock(22 Ma).
- Transformation ratio of the Cenomanian source rock(Present Day).
- Transformation ratio of the Pal_Eocene source rock (30 Ma).
- Transformation ratio of the Pal_Eocene source rock (22 Ma).